Data dashboard

These files provide price and demand data by region, cumulated by month. They are in simple CSV format and the data in them can be easily graphed using standard desktop applications. The data dates back to the start of the NEM, 13 December 1998.

QLD

NSW

VIC

TAS

SA

Download Current Month

Aggregated Price and Demand Data - Historical

Warning: The data in these files is updated and extended by automatic processes at the end of each day. Price data is subject to review and occasional adjustment by the end of the next business day, in accordance with National Electricity Rule 3.8.1(c) and the Over Constrained Dispatch procedure. Prices become final on the second business day of the following month.

QLD

NSW

VIC

TAS

SA

Download Historic Data as .csv

Average Daily Prices - Current Month

The Average Price table shows average prices for each day in the current month. RRP refers to the average spot price ($/MWh) per region for each day, and PEAK RRP refers to the average peak price from 7:00am to 10:00pm EST (weekdays excluding NEM Holidays). Please note that under the historical data the annual year refers to the financial year, not calendar year.

Average Prices - Historical

Index to tables showing average prices in the past.

Annual

Monthly

Daily

Download this data | CSV

Operational Demand in a region is demand that is met by local scheduled generating units, semi-scheduled generating units, and non-scheduled intermittent generating units of aggregate capacity ≥ 30 MW, and by generation imports to the region. It excludes the demand met by non-scheduled non-intermittent generating units, non-scheduled intermittent generating units of aggregate capacity < 30 MW, exempt generation (e.g. rooftop solar, gas tri-generation, very small wind farms, etc), and demand of local scheduled loads. The exceptions are Yarwun, Angaston, Port Stanvac, and Morton’s Lane which are included.

Probability of Exceedance (POE) demand is a generalised approach to defining the probability of exceedance of electricity demand forecasts. The demand is expressed as the probability the forecast would be met or exceeded, e.g. a 50% POE demand implies there is a 50% probability of the forecast being met or exceeded.

Daily Actual Operational Demand Update - filename: public_actual_operational_demand_update_daily*.csv (approx. size 2Mb)
This file is published when there is a retrospective change made by AEMO to the actual operational demand data record (for example: due to SCADA data quality). Data published here overrides the original data published in real-time (Half-hourly Actual Operational Demand and Daily Actual Operational Demand files) for the same trading interval.

weekly files for the Half-hourly Actual and Forecast Operational Demand

monthly files for the Daily Actual Operational Demand

Note:

The National Electricity Market registration classification of Yarwun Power Station Unit 1 (dispatchable unit ID: YARWUN_1) is market non-scheduled generating unit. However, it is a condition of the registration of this unit that the Registered Participant complies with some of the obligations of a Scheduled Generator. This unit is dispatched as scheduled generating unit with respect to its dispatch offers, targets and generation outputs. Accordingly, information about YARWUN_1 is reported as scheduled generating unit information.

Disclaimer

This data is provided for information only and is not intended for commercial use. AEMO does not guarantee the accuracy of the data or its availability at all times.

Explanation of Terms

Scheduled Capacity

The total forecast generating capacity, available to the region at the time of its forecast daily peak demand (as limited by any network constraints), based on:

The offered maximum availability of all scheduled generation within that region, as limited by any offered daily energy limitations.

The unconstrained intermittent generation forecasts of all semi-scheduled generation within that region.

This figure does not include net import from other regions.

Scheduled Demand

The forecast daily peak demand for the region, based on weather-adjusted forecasts by AEMO with a 50% probability of exceedance, to be met by scheduled and semi-scheduled generation (either locally or via interconnector imports).